US10705068B2 - System and method for measuring a flow property of a fluid in a porous medium - Google Patents

System and method for measuring a flow property of a fluid in a porous medium Download PDF

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US10705068B2
US10705068B2 US16/070,540 US201616070540A US10705068B2 US 10705068 B2 US10705068 B2 US 10705068B2 US 201616070540 A US201616070540 A US 201616070540A US 10705068 B2 US10705068 B2 US 10705068B2
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fluid
cell
rays
porous medium
injecting
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US20190056376A1 (en
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Souhail YOUSSEF
Yannick Peysson
Herve Deschamps
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IFP Energies Nouvelles IFPEN
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    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N33/00—Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00
    • G01N33/24—Earth materials
    • G01N33/241—Earth materials for hydrocarbon content
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N11/00—Investigating flow properties of materials, e.g. viscosity, plasticity; Analysing materials by determining flow properties
    • G01N11/02—Investigating flow properties of materials, e.g. viscosity, plasticity; Analysing materials by determining flow properties by measuring flow of the material
    • G01N11/04—Investigating flow properties of materials, e.g. viscosity, plasticity; Analysing materials by determining flow properties by measuring flow of the material through a restricted passage, e.g. tube, aperture
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N15/00—Investigating characteristics of particles; Investigating permeability, pore-volume or surface-area of porous materials
    • G01N15/08—Investigating permeability, pore-volume, or surface area of porous materials
    • G01N15/082—Investigating permeability by forcing a fluid through a sample
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N11/00—Investigating flow properties of materials, e.g. viscosity, plasticity; Analysing materials by determining flow properties
    • G01N2011/006—Determining flow properties indirectly by measuring other parameters of the system
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N15/00—Investigating characteristics of particles; Investigating permeability, pore-volume or surface-area of porous materials
    • G01N15/08—Investigating permeability, pore-volume, or surface area of porous materials
    • G01N2015/0846—Investigating permeability, pore-volume, or surface area of porous materials by use of radiation, e.g. transmitted or reflected light
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N23/00—Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups G01N3/00 – G01N17/00, G01N21/00 or G01N22/00
    • G01N23/02—Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups G01N3/00 – G01N17/00, G01N21/00 or G01N22/00 by transmitting the radiation through the material
    • G01N23/04—Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups G01N3/00 – G01N17/00, G01N21/00 or G01N22/00 by transmitting the radiation through the material and forming images of the material

Definitions

  • the present invention relates to the field of flow property measurement of a fluid in a porous medium, notably a porous medium from an underground formation. Measurements can be used notably for determining the residual oil saturation of an underground formation, in particular during the exploration and exploitation of hydrocarbon wells, and especially for enhanced oil recovery (EOR).
  • EOR enhanced oil recovery
  • the invention relates to a system and to a method for measuring at least one flow property of at least one fluid in a porous medium.
  • the measurement system comprises at least one cell, means for injecting fluid(s) into the cell and X-ray radiography means. Using X-ray radiography means in a cell into which a fluid can be injected allows measurements to be performed rapidly and in real time.
  • the invention relates to a system for measuring at least one flow property of at least one fluid in a porous medium.
  • Said measurement system comprises at least one cell containing said porous medium, means for injecting said fluid into said cell and X-ray radiography means including a source and a detector, said X-ray radiography means being suited to perform a plurality of X-rays upon injection of said fluid.
  • said measurement system comprises means for controlling said injection means.
  • said measurement system comprises means for collecting and/or analyzing said X-rays obtained by said detector.
  • said cell has a substantially cylindrical shape.
  • the diameter of said cell substantially ranges between 2 mm and 5 cm, preferably between 5 mm and 2 cm.
  • said injection means comprise a plurality of fluids to be injected into said cell, simultaneously or sequentially.
  • said injection means comprise at least one pump, at least one valve and at least one pressure detector.
  • said fluid is selected from among an aqueous phase and an oil phase.
  • At least one aqueous phase comprises at least one additive, notably a surfactant.
  • said measurement system comprises means for positioning said cell.
  • the invention relates to a method for measuring at least one flow property of at least one fluid in a porous medium, wherein said measurements are performed by means of said measurement system according to one of the above characteristics.
  • said flow properties are selected from among the average saturation of said fluid and/or the saturation profile of said fluid and/or the pressure difference of said fluid within said sample.
  • a plurality of X-rays are performed upon injection of said fluid.
  • a plurality of X-rays are performed at regular intervals substantially ranging between 0.1 and 5 seconds.
  • a residual saturation curve is plotted as a function of the flood capillary number by means of said measurements.
  • the X-ray radiography measurements are performed by means of said measurement system while carrying out the following injection steps in said cell:
  • FIG. 1 illustrates a measurement system according to an embodiment of the invention
  • FIG. 2 illustrates the average oil saturation and the pressure difference for an example of a method according to the invention
  • FIG. 3 illustrates the oil saturation profile along the sample during the drainage phase at several times for the example of FIG. 2 .
  • FIG. 4 illustrates the oil saturation profile along the sample during the surfactant flooding phase at several flow rates for the example of FIG. 2 .
  • FIG. 5 shows the residual saturation measured with the system as a function of the flood capillary number for two rock types for the example of FIG. 2 .
  • the present invention relates to a system for measuring at least one flow property of at least one fluid in a porous medium.
  • the flow properties can notably be the average saturation of the fluid and/or the saturation profile of the fluid and/or the pressure difference of the fluid in the porous medium, etc.
  • the flow properties can depend on the operating parameters and on the flow rates of each fluid.
  • the fluid can be of any type, it can notably comprise an aqueous phase, an oil phase. . . .
  • the fluid can further comprise at least one additive, a surfactant for example.
  • Surfactants exhibit the property of decreasing very significantly the interfacial tension between water and oil, or even of nearly cancelling it out.
  • the porous medium can be of any type, it can notably consist of a rock sample taken from an underground formation, or it can be a porous polymer. In cases where the porous medium is a rock, it is possible to characterize the fluid(s) flows in the underground formation.
  • the measurement system according to the invention comprises:
  • the X-ray radiography means allow to perform measurements of the fluid flow property in the porous medium contained in the cell. Indeed, through calibration, it is possible to connect the grey level of the X-ray image obtained to the saturation in the porous medium. A previous image can therefore be performed with the sample saturated with at least one fluid to be injected in the porous medium. Thus, it is possible to have “reference” X-rays, to be compared with the X-rays made during injection. For example, in the case of a measurement relative to a rock sample, a first X-ray can be performed for a water-saturated sample, then a second X-ray can be performed for an oil-saturated sample. Using a plurality of X-rays also allows fast measurement (of the order of one hour, to be compared with the few weeks required for current measurements) in real time.
  • the radiography means and the cell can be inside an X-ray protection cabin, while the other components of the measurement system, notably the fluid injection means, can be outside the protection cabin.
  • the measurement system can comprise the following elements, alone or in combination:
  • the measurement system comprises both means for controlling the injection means and X-ray collection and/or analysis means
  • a single computer system can fulfil these two functions.
  • the cell of the measurement system can have a substantially cylindrical shape.
  • the cell has small dimensions (it is then referred to as mini-sample) in relation to the conventional sizes used for oil saturation measurements. These conventional dimensions are of the order of 5 cm in diameter and 10 cm in length.
  • the diameter of the cell substantially ranges between 2 mm and 3 cm, preferably between 5 mm and 2 cm.
  • the diameter of the cell can be approximately 1 cm.
  • the length (height) of the cell can range between 5 and 50 mm, and it can for example be approximately 20 mm.
  • the reduced dimensions of the cell in relation to the samples conventionally used allow measurements to be performed more rapidly, notably because the injection times can be shorter. Thanks to shorter experiment durations, the mini-samples also allow to carry out several experiments and to study the desired results statistically.
  • the cell can be intended to operate at temperatures close to 150° C. and at pressures close to 150 bars.
  • the means for injecting the fluid into the cell can be suited to inject a single fluid.
  • the injection means can be suited to inject a plurality, for example 2 to 5 fluids, into the cell.
  • injection of the various fluids can be performed sequentially or simultaneously.
  • the possibility of injecting different fluids allows to provide particular injection sequences in order to determine certain properties of the flow in the sample. For example, when studying a surfactant for an EOR method, it is feasible to provide three fluids to be injected: water, oil and an aqueous phase comprising a surfactant.
  • the means for injecting the fluid into the cell can comprise means for adjusting the rate of injection of the fluid into the cell, a flowmeter for example, in order to perform flow rate-dependent measurements.
  • the fluid injection means can comprise at least one pressure regulator for regulating the pressure of the fluid injected into the cell.
  • the X-ray radiography means can be suited to perform X-rays at regular intervals during the injection of fluid (s).
  • the regular interval can range between 0.1 and 5 seconds, and it can be 1 second for example.
  • performing X-rays at regular intervals allows regular monitoring of the flows in the cell, which enables real-time monitoring of the flows in the sample.
  • FIG. 1 schematically shows, by way of non-limitative example, a measurement system according to an embodiment of the invention.
  • Measurement system 1 comprises a cell 2 containing a rock sample (not shown), or any other porous medium.
  • Cell 2 is arranged in an X-ray protection cabin 3 .
  • Cabin 3 also comprises X-ray radiography means including an X-ray source 4 and an X-ray detector 5 .
  • Cell 2 is placed on a support that can be shifted along three axes (schematically shown by arrows).
  • Measurement system 1 also comprises means 7 for injecting the fluid into the cell.
  • Injection means 7 are provided with four fluids.
  • Injection means 7 are connected to the cell by four lines.
  • Injection means 7 are arranged outside X-ray protection cabin 3 .
  • measurement system 1 comprises a computer system 6 .
  • Computer system 6 is connected to detector 5 and to injection means 7 .
  • Computer system 6 is used for controlling injection means 7 and the collection and analysis means intended for the X-rays obtained by detector 5 .
  • Computer system 6 is arranged outside protection cabin 3 .
  • the present invention also relates to a method for measuring at least one flow property of at least one fluid in a porous medium.
  • the measurement method according to the invention is based on the use of the measurement system according to the invention.
  • the method according to the invention can comprise the following steps;
  • the method according to the invention allows to measure at least one of the following properties: the average saturation of a fluid injected into the porous medium, the saturation profile of a fluid injected into the porous medium, the pressure difference of the fluid injected into the porous medium, etc.
  • the method according to the invention can be used within the context of an enhanced oil recovery (EOR) process wherein the method according to the invention is used with the measurement system according to the invention to determine the formulation of the composition (water and at least one additive, including a surfactant) injected into the underground formation.
  • the porous medium used corresponds to a rock sample taken from the underground formation where the EOR process is implemented.
  • the X-ray radiography means can be suited to perform X-rays at regular intervals during the fluid injection(s).
  • the regular interval can range between 0.1 and 5 seconds, and it can be 1 second for example.
  • performing X-rays at regular intervals allows regular monitoring of the flows in the cell, which enables real-time monitoring of the flows in the sample.
  • the method according to the invention can comprise the following injection sequence:
  • this sequence can comprise the following steps:
  • the method according to the invention can comprise simultaneous injection of water and oil for different flow rates. These common injections notably allow the relative permeability to be measured.
  • the system and the method according to the invention are implemented during a sequence aimed to characterize the evolution of the residual oil saturation during various water and surfactant flooding operations at different flow rates.
  • a 10 mm diameter and 19 mm long sandstone sample is used in one of the cells.
  • the sample is initially 100% saturated with water.
  • the injection sequence performed by the measurement system illustrated in FIG. 1 is as follows:
  • FIG. 3 and FIG. 4 show two examples of oil saturation profiles So as a function of the depth of the sample x (mm), obtained during drainage phase E 1 and during the surfactant flooding phase E 4 .
  • the boundaries of the samples are symbolized by discontinuous vertical lines and the direction of injection is shown by an arrow.
  • the oil saturation increases during the drainage phase.
  • the profiles obtained allow to measure the residual saturation for each water and surfactant flooding stage E 4 . It is then possible to plot the residual saturation curve Sor/Sor* (with Sor the residual saturation and Sor* the normalized residual saturation) as a function of the flood capillary number Nc ( FIG. 5 ), which is an important datum for any EOR survey.
  • Capillary number Nc is the ratio between the average flood flow velocity times the water viscosity divided by the interfacial tension between the water/surfactant system and the oil.
  • two curves are obtained for two different sandstone samples with the same experimental sequence: Bentheimer sandstone and Clashach sandstone.

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US16/070,540 2016-01-29 2016-12-15 System and method for measuring a flow property of a fluid in a porous medium Active 2036-12-17 US10705068B2 (en)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
FR1650711A FR3047315A1 (fr) 2016-01-29 2016-01-29 Systeme et procede de mesure d'une propriete d'ecoulement d'un fluide au sein d'un milieu poreux
FR1650711 2016-01-29
PCT/EP2016/081139 WO2017129312A1 (fr) 2016-01-29 2016-12-15 Systeme et procede de mesure d'une propriete d'ecoulement d'un fluide au sein d'un milieu poreux

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US20190056376A1 US20190056376A1 (en) 2019-02-21
US10705068B2 true US10705068B2 (en) 2020-07-07

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US (1) US10705068B2 (de)
EP (1) EP3408669B1 (de)
BR (1) BR112018014118B1 (de)
CA (1) CA3010454C (de)
FR (1) FR3047315A1 (de)
MX (1) MX2018008780A (de)
MY (1) MY196976A (de)
SA (1) SA518392096B1 (de)
WO (1) WO2017129312A1 (de)

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US11408811B2 (en) * 2020-02-04 2022-08-09 Saudi Arabian Oil Company Methods and systems for determining residual fluid saturation of a subsurface formation

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FR3086394B1 (fr) 2018-09-21 2020-10-16 Ifp Energies Now Systeme et procede de mesure d’une propriete d’ecoulement d’un fluide dans un milieu poreux avec correction
FR3088118B1 (fr) 2018-11-05 2020-10-23 Ifp Energies Now Systeme et procede de tracage d’especes ioniques par mesures electriques multiples
CN110672468B (zh) * 2019-10-31 2023-04-07 中国石油天然气股份有限公司 一种流体粘度测量装置及方法
FR3104722B1 (fr) 2019-12-16 2024-06-21 Ifp Energies Now Procédé d’évaluation de l’efficacité de composés biocides vis-à-vis de micro-organismes colonisant des matériaux poreux
WO2021137152A1 (en) 2019-12-31 2021-07-08 3M Innovative Properties Company Curable oral care composition containing silver and fluoride
US11913865B2 (en) * 2020-01-08 2024-02-27 Khalifa University of Science and Technology In-situ prediction and dynamic visualization of relative permeability and capillary pressure in porous medium
FR3111706B1 (fr) 2020-06-19 2022-06-03 Ifp Energies Now Procédé pour déterminer le volume poreux d'un échantillon de milieu poreux
FR3116607A1 (fr) 2020-11-26 2022-05-27 IFP Energies Nouvelles Installation mobile de mesure d’au moins une propriété d’écoulement d’au moins un fluide dans un milieu poreux
FR3119889B1 (fr) 2021-02-17 2024-09-06 Ifp Energies Now Cellule de mesure d’au moins une propriété d’écoulement d’au moins un fluide dans un milieu poreux
WO2023222767A1 (en) * 2022-05-17 2023-11-23 Totalenergies Onetech A porous sample wettability parameter determining method and related system

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CA3010454C (fr) 2023-07-18
FR3047315A1 (fr) 2017-08-04
SA518392096B1 (ar) 2022-02-02
MX2018008780A (es) 2018-09-12
MY196976A (en) 2023-05-16
WO2017129312A1 (fr) 2017-08-03
BR112018014118B1 (pt) 2022-10-04
EP3408669A1 (de) 2018-12-05
US20190056376A1 (en) 2019-02-21
EP3408669B1 (de) 2022-02-23
CA3010454A1 (fr) 2017-08-03
BR112018014118A2 (pt) 2018-12-11

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